@ N FX isperiodically publishedtokeepstockholdersaw areofcurrentoperatingactivitiesatN ew field.Itm ay includeestim atesofexpected productionvolum es,costsandexpenses,recentchangestohedgingpositionsandcom m odity pricing.

@ NFX

3Q 14 U pdateO ctober28,2014

T ableofContents

Highlights 3

P roductionby FocusArea 4

FocusAreaU pdates 5

–AnadarkoBasin 6

– U intaBasin 13

– W illistonBasin 14

S um m ary ofW ellR esults 15

Guidance 16

DerivativeP ositionS um m aries 17

2

A llfinancialandoperationaldatarefersto“ContinuingO perations”

Highlights

3Q 14 productionexceedsguidancem id-pointby~0.5 M M BO E

3Q 14 cashflow from operations:~$321 M M ;3Q 14adjustednetincom e:$72 M M

FY14eproductionestim atedtoreachupper-end ofguidance(~47.4 M M BO E)

S trongexecutionineachfocusarea

S uccessfully tested S T ACKverticalspacingpilot;continued productiondelineationofS T ACK

Announced positionin“N EW ” S pringerplay

R eceived >$600 M M proceedsfrom saleofnon-strategicassets

– Called$600M M S eniorS ubordinatedN otesdue2018

Com m enced P earldevelopm entdrilling

2014eCapitalbudgetraised$50 M M to$1.75 B

– R eflectsadditionalacreageandactivity inS T ACK3

3Q 14 P roductionby P roduct

~56%

LiquidsGas

~44%

3Q 14 N ET P R O DU CT IO N (M M BO E)

O il 4.80

N GL s 2.24

Gas 5.62

T O T A L 12.66

0

20

40

60

80

100

120

140

MB

OEP

D(n

et)

EagleFord

W illiston

Anadarko*

U inta

*IncludesS CO O P andS T A CK;ExcludesGraniteW ash

** Com pany planstoupdateits2015-16 guidanceinFeb.2015

4

P roductionby FocusA rea

~105 M BO EP D

T obeupdatedinFeb.2015

O utperform inginEachFocusA rea

FocusA rea

2013P roduction(M M BO E)

2014 O riginalGuidance(M M BO E)

2014 FinalGuidance(M M BO E)

Delta

(M M BO E)

% Change Y-o-YGrow th

A nadarkoBasin

7.2 14.3 14.8 0.5 3% 106%

U intaBasin

8.2 8.6 9.4 0.8 9% 15%

W illistonBasin

4.4 6.0 6.5 0.5 8% 48%

EagleFord

3.0 4.0 4.2 0.2 5% 40%

T O T A L 22.8 32.9 34.9 2.0 6% 53%

5

2014eT otalDom esticP roduction:47.4 M M BO E

A nadarkoBasin*

Increasedacreageto~275,000 netacres

> 15% productiongrow thover2Q 14and> 100% over3Q 13

> 20% liquidsgrow thover2Q 14 and> 80%over3Q 13

2014eproductiontom orethandoubleover2013 volum es

Continuedhighliquidscut;gas/oilratiosrem ainconsistentw ithm odelforecast

AchievedYE14 exitratetargetof50,000BO EP D (net)

0

10,000

20,000

30,000

40,000

50,000

BOEPD(net)

AnadarkoDailyProduction*

Liquids Gas

NETAVG.PRODUCTION(BOEPD)

FY2013 3Q14 FY2014e

Liquids 10,844 26,000 23,500

Gas 8,842 19,000 17,100

TOTAL 19,686 45,000 40,600

*IncludesSCOOPandSTACK;ExcludesGraniteWash

6

S T ACK P roduction-DelineationContinues…

7

Slash C620BOEPD IP30-dayavg.

(84% Oil)

John821BOEPD IP30-dayavg.

(84% Oil)

Connie935BOEPD IP30-dayavg.

(87% Oil)

Johnisthefurtheststep-outw ellto-datetothenorthw est

Connie& Freem anarethefirstM eram ec“ S T ACKed” verticalspacingtests.Afterinitial30-daysofproduction,nointerference;w ellsabovetypecurve

S lashC recent“ best-in-class” w elldrilled andcom pletedfor$9.8M M

Com pany hasproduction-delineated~2/3 ofS T ACK acreage

Currently Drilling

Freem an680BOEPD IP30-dayavg.

(85% Oil)

S T ACK VerticalS pacingT est

M eram ecS hale~400’

8

S T ACKVerticalS pacingT est

ConnieW ell(U pperM eram ec)

– 935 BO EP D IP 30-day avg.(87% oil)

Freem anW ell(L ow erM eram ec)

– 680 BO EP D IP 30-day avg.(85% oil)

S paced~275’ vertically inM eram ec

S paced~880’ acrossleaseline 275’

880’

0

5

10

15

20

25

30

0

100

200

300

400

500

600

700

800

0 200 400 600

Wel

lCo

un

t

BO

EPD

DaysO nline

S T ACK T ypeCurve 18w ellsplotted againsttypecurve

– 10,090’ averagelaterallength

S T ACKW ellP erform ance

T ypeCurve(9,000’)

Actual

W ellCount

9

25 w ellsplotted againsttypecurve

– 8,120’ averagelaterallength

“N EW ” Briardevelopm ent(4 S X Linfillw ells)

– Briar1H and2H w ellsaverage60-day rate:1,250 BO EP D (53% oil)

– Briar3H and4H w ellsaverage30-day rate:1,375 BO EP D (~50% oil)

T ypeCurve(8,900’)

Actual

W ellCount

S CO O P O ilW ellP erform ance

10

0

5

10

15

20

25

30

0

200

400

600

800

1,000

1,200

1,400

1,600

1,800

2,000

0 100 200 300 400 500 600

Wel

lCo

un

t

BO

EPD

DaysO nline

S CO O P O ilT ypeCurves

P roductiondataexcludes3w ellsshut-inforoffsettingfracs

S CO O P W etGasW ellP erform ance

11

32 w ellsplottedagainsttypecurve

– 6,011’ averagelaterallength

0

5

10

15

20

25

30

35

0

200

400

600

800

1,000

1,200

1,400

1,600

1,800

0 100 200 300 400 500 600

Wel

lCo

un

t

BO

EPD

DaysO nline

S CO O P W etGasT ypeCurve

T ypeCurve(5,900’)

Actual

W ellCount

S pringerS haleS trengthensS CO O P Inventory

Addsinventory toHBP S outhS CO O Pacreage

U pto150’ thick

Highly siliceous,organicrich

Highperm eability andporosity

O ver-pressured

R ecentoperated w ell:

– Jarred(4,850’ lateral)

1,950 BO EP D 24-hrIP (85% oil)

1,220 BO EP D 30-day avg.(81% oil)

T hreerecentnon-operated S pringerw ellshadaverage24-hrIP ratesof1,494BO EP D

12

U intaBasin

Forecasting15% YoY grow thin‘14;(up> 800,000 BO Efrom originalforecast)

S X L drillingcam paigninCentralBasindeliveringencouragingresults

– R ecent“ best-in-class” U teland Buttew elldrilled andcom pleted for~$10.8M M

R efinery expansionsunderw ay

R ailm arketsexpanding

0

10,000

20,000

30,000

BOEPD(net)

UintaDailyProduction

Liquids Gas

NETAVG.PRODUCTION(BOEPD)

FY2013 3Q14 FY2014e

Liquids 18,140 20,800 21,100

Gas 4,389 5,000 4,700

TOTAL 22,529 25,800 25,800

13

W illistonBasin

~8% productiongrow thover2Q 14 and45% over3Q 13

YT D S X L saverage~$7.5M M (includingfacilities)

– Full-field developm ent,targetingM iddleBakkenand T hree-Forks1

– Im provedefficienciesthroughpad drillingand optim ized com pletions

– R ecent“ best-in-class” W ehrung4H(9,900’ lateral)

$6.8 M M com pleted w ellcost(includingfacilities)

– 2,775 BO EP D 24-hrIP

– 878BO EP D 30-day avg.

– 694 BO EP D 60-day avg.

– 609 BO EP D 90-day avg.

0

5,000

10,000

15,000

20,000

BOEPD(net)

WillistonDailyProduction

Liquids Gas

NETAVG.PRODUCTION(BOEPD)

FY2013 3Q14 FY2014e

Liquids 10,337 16,100 14,900

Gas 1,852 3,300 2,900

TOTAL 12,189 19,400 17,800

14

YT D S um m ary ofW ellR esults

W ellT ype # W ellsAvg.

GrossIP

(24-Hours)

Avg.

Gross

30-Day R ate

Avg.

Gross

60-Day R ate

Avg.

Gross

90-Day R ate

S CO O P W etGasS X L 5 2,006 BO EP D 1,615 BO EP D 1,646 BO EP D 1,550 BO EP D

S CO O P W etGasX L 13 1,377 BO EP D 1,054 BO EP D 1,042 BO EP D 1,022 BO EP D

S CO O P O il(1) 17 1,511 BO EP D 1,194 BO EP D 1,166 BO EP D 977BO EP D

S T ACK(2) 10 931 BO EP D 651 BO EP D 580 BO EP D 581 BO EP D

U teland ButteS X L 3 2,157 BO EP D 1,449 BO EP D 1,251 BO EP D 1,067 BO EP D

W asatchS X L 2 2,068 BO EP D 1,428 BO EP D 1,479 BO EP D 1,241 BO EP D

W illistonBasin(3)(4) 39 2,369 BO EP D 821 BO EP D 671 BO EP D 599 BO EP D

EagleFordS X L (5) 9 874 BO EP D 783 BO EP D 735 BO EP D 734 BO EP D

(1)30-day rateincludes16 w ells,60-day rateincludes13 w ellsand90-day rateincludes7 w ells

(2)60-day rateincludes6 w ellsand90-day rateincludes3 w ells

(3)Includes31 M iddleBakkenw ellsand8T hreeForksw ells

(4)30-day rateincludes36 w ells,60-day rateincludes34 w ellsand90-day rateincludes28 w ells

(5)90-day rateincludes5 w ells

15

2014e 3Q 14 4Q 14e

P roduction:O il(M M BO ) 18.4 4.8 5.0

N GL s(M M Bbls) 8.0 2.2 2.1

N aturalGas(BCF) 126 33.7 29.4

T otal(M M BO E) 47.4 12.72 12.02

T otalL O E($M M ) $483 $126 $127

P roduction& O therT axes($M M )3 $115 $31 $30

DD&A Expense($M M ) $845 $228 $217

General& A dm inistrative(G&A ),net($M M ) $222 $48 $50

CapitalizedInternalCosts($M M ) ($134) ($23) ($25)

O therO peratingExpense($M M ) $8 $8 --

InterestExpense($M M ) $195 $51 $42

CapitalizedInterest($M M ) ($52) ($13) ($13)

P rem ium onCallofN otes($M M )4 $14 -- $14

1 P roduction,CostsandExpensesarebasedoncontinuingoperationsandCostsand Expensesareexpectedtobew ithin7% oftheestim atesabove.2 T hirdquarteractualresultsand reportedguidancereflecttherem ovalof0.1 M M BO Ein3Q 14 and0.9 M M BO Ein4Q 14eduetothesaleofGraniteW ash.3 T ableA ssum es1Q 14 – 3Q 14 actualcom m odity prices& stripcom m odity pricesfor4Q 144 4Q 14erelatestoaone-tim eprem ium paym enttocallour$600M M 71/8% S eniorS ubordinatedN otesin4Q 14

P roduction,Cost& ExpenseGuidance1

16

Volum e/day W eighted-AverageP rice

P eriod Bbls S w apsS w apsw / S hort

P uts2 CollarsCollarsw / S hort

P uts1

4Q 201423,00016,0006,000

$89.94——

—$75.00/95.16

—

———

——

$75.83/90.83-$102.93

1Q 20158,000

38,5002,000

$90.63——

—$72.03/90.08

—

———

——

$75.00/90.00-$104.00

2Q 20159,000

38,5002,000

$90.01——

—$72.03/89.96

—

———

——

$75.00/90.00-$104.00

3Q 20157,000

41,0002,000

$90.00——

—$71.65/89.95

—

———

——

$75.00/90.00-$104.00

4Q 20151,000

46,5002,000

$90.00——

—$71.12/90.08

—

———

——

$75.00/90.00-$104.00

O ilHedgingDetailsasof10/28/14

N ote:P eriodically,w esellputoptionsagainstpreviously entered intofixed-price sw apsorcollarsinordertoenhancethepriceofnew positions.Assuch,putoption contractsm ay beentered intoatdifferenttim esandw ithdifferentcounterpartiesascom pared toouropenfixed-price sw aporcollarcontracts.How ever,w edonotsellputoptionsforvolum esinexcessofouropenfixed-price sw aporcollarcontracts.

1 Below $75.83 perBblin2014 and below $75.00 in2015,thesecontractseffectively resultinrealized pricesthatareonaverage$15.00 perBblhigherthanthecashpricethatotherw isew ould havebeenrealized.2 Below $75.00 perBblfor2014,$72.03 perBblfor1Q 2015,$72.03 perBblfor2Q 2015,$71.65perBblfor3Q 2015,and $71.12 perBblfor4Q 2015,thesecontractseffectively resultinrealized pricesthatareonaverage$20.16,$18.05,$17.93,$18.30,and $18.96perBblhigher,respectively,thanthecashpricethatotherw isew ould havebeenrealized.

17

Denotesupdate

O ilHedgingDetailsasof10/28/14Volum e/day W eighted-AverageP rice

P eriod Bbls S w apsS w apsw / S hort

P uts2 CollarsCollarsw / S hort

P uts1

1Q 2016 33,00017,000

——

$73.48/89.97—

——

—$75.00/90.00-$96.30

2Q 2016 27,00019,000

——

$74.44/89.99—

——

—$75.00/90.00-$96.32

3Q 2016 27,00016,000

——

$74.44/90.03—

——

—$75.00/90.00-$95.98

4Q 2016 23,00016,000

——

$74.35/89.90—

——

—$75.00/90.00-$95.98

1Q 2017 15,00013,000

——

$73.73/89.23—

——

—$75.00/90.00-$95.52

2Q 2017 10,00010,000

——

$73.10/88.09—

——

—$75.00/90.00-$95.69

3Q 2017 13,000—

——

$73.08/87.90—

——

——

4Q 2017 11,000—

——

$73.09/88.01—

——

——

1 Below $75.00 perBblin2016and 2017,thesecontractseffectively resultinrealized pricesthatareonaverage$15.00 perBblhigherthanthecashpricethatotherw isew ould havebeenrealized.2 Below $73.48perBblfor1Q 2016,$74.44 perBblfor2Q 2016,$74.44 perBblfor3Q 2016,$74.35perBblfor4Q 2016,$73.73 perBblfor1Q 2017,$73.10 perBblfor2Q 2017,$73.08perBblfor3Q 2017,and $73.09 perBblfor4Q 2017,thesecontractseffectively resultinrealized pricesthatareonaverage$16.49,$15.55,$15.59,$15.55,$15.50,$14.99,$14.82 and $14.92 perBblhigher,respectively,thanthecashpricethatotherw isew ould havebeenrealized.

N ote: W ehaveentered intosw aption contractsthatw ould potentially hedge732,000 barrelsof2016production atasw appriceof$91.00 ifexercised ontheirexpiration dateofM arch31,2015.Any futurepotentialsettlem entvaluew illbeexcluded hereinunlessand untilthesw aptionsareexercised.

18

O ilHedgingDetailsasof10/28/14

O ilP rices

P eriod $70 $80 $90 $100 $110

4Q 2014 $80 $49 $8 ($28) ($69)

1Q 2015 $78 $44 $1 ($41) ($84)

2Q 2015 $80 $45 $0 ($43) ($88)

3Q 2015 $82 $46 $0 ($44) ($90)

4Q 2015 $80 $46 $0 ($43) ($88)

1Q 2016 $72 $45 $0 ($36) ($81)

2Q 2016 $64 $42 $0 ($31) ($73)

3Q 2016 $61 $40 $0 ($31) ($70)

4Q 2016 $55 $36 $0 ($27) ($63)

1Q 2017 $38 $24 ($1) ($20) ($45)

2Q 2017 $27 $16 ($2) ($15) ($33)

3Q 2017 $18 $9 ($3) ($14) ($26)

4Q 2017 $15 $8 ($2) ($12) ($22)

T hefollow ingtabledetailstheexpectedim pacttopre-taxincom e(inm illions,exceptprices)from thesettlem entofourderivativecontracts,outlinedonthepreviousslide,atvariousN YM EX oilprices.

19

GasHedgingDetailsasof10/28/14

Volum e/day W eighted-AverageP rice

P eriod M M Btus S w apsS w apsw / S hort

P utsCollars

Collarsw / S hortP uts

4Q 2014 221,70065,000

$3.97—

——

—$3.75 -$4.62

——

1Q 2015 135,000105,000

$4.28—

——

—$3.93 -$4.74

——

2Q 2015 135,000105,000

$4.28—

——

—$3.93 -$4.74

——

3Q 2015 135,000105,000

$4.28—

——

—$3.93 -$4.74

——

4Q 2015 135,000105,000

$4.28—

——

—$3.93 -$4.74

——

20

GasHedgingDetailsasof10/28/14

GasP rices

P eriod $3 $4 $5 $6

4Q 2014 $24 ($1) ($23) ($50)

1Q 2015 $24 $3 ($11) ($33)

2Q 2015 $25 $3 ($12) ($33)

3Q 2015 $25 $3 ($12) ($34)

4Q 2015 $25 $3 ($12) ($34)

T hefollow ingtabledetailstheexpectedim pacttopre-taxincom e(inm illions,exceptprices)from thesettlem entofourderivativecontracts,outlinedonthepreviousslide,atvariousN YM EX gasprices.

21

W eprovideinform ationregardingouroutstandinghedgingpositionsinourannualandquarterly reportsfiledw iththeS EC andinourelectronicpublication--@ N FX . T hispublicationcanbefoundonN ew field’sw ebpageathttp://w w w .new field.com .T hroughthew ebpage,you m ay electtoreceive@ N FX throughe-m aildistribution.

N ew fieldExplorationCom panyisanindependentenergy com panyengagedintheexploration,developm entandproductionofcrudeoil,naturalgasandnaturalgasliquids.W earefocusedonN orthAm ericanresourceplaysandourprincipalareasofoperationincludetheM id-Continent,theR ocky M ountainsandonshoreGulfCoast.

T hispresentation containsforw ard-looking statem entsw ithin the m eaning ofS ection 27A ofthe S ecuritiesA ct of1933,asam ended,and S ection 21E ofthe

S ecuritiesExchange A ct of1934,asam ended. T he w ords“w ill”,“believe”,“intend”,“plan”,“expect” orothersim ilarexpressionsare intended to identify

forw ard-looking statem ents. O therthan historicalfactsincluded in thispresentation,allinform ation and statem ents,such asinform ation regarding planned

capitalexpenditures,estim ated reserves,estim ated production targets,drillingand developm entplans,the tim ingofproduction,planned capitalexpenditures,

and otherplansand objectivesforfuture operations,areforw ard-lookingstatem ents.A lthough asofthe date ofthispresentation N ew field believesthatthese

expectationsare reasonable,thisinform ation isbased upon assum ptionsand anticipated resultsthat are subject to num erousuncertaintiesand risks.A ctual

resultsm ay vary significantly from those anticipated due to m any factors,including drilling results,com m odity prices,industry conditions,the pricesofgoods

and services,theavailability ofdrillingrigsand othersupportservices,theavailability ofrefiningcapacity forthecrudeoilN ew field producesin theU intaBasin

in U tah,the availability ofcapitalresources,laborconditions,severe w eatherconditions,governm entalregulationsand otheroperating risks. P lease see

N ew field’s2013 A nnualR eportonForm 10-K and subsequentQ uarterly R eportsonForm 10-Q filed w iththeU .S .S ecuritiesand ExchangeCom m ission(S EC)fora

discussion ofotherfactorsthat m ay cause actualresultsto vary.U npredictable orunknow n factorsnot discussed herein orin N ew field’sS EC filingscould also

havem aterialadverseeffectsonforw ard-lookingstatem ents. R eadersarecautionednottoplaceundorelianceonforw ard-lookingstatem ents,w hichspeakonly

asofthedateofthispresentation. U nlesslegally required,N ew field undertakesnoobligation topublicly updateorreviseany forw ard-lookingstatem ents.

Cautionary N ote to Investors– Effective January 1,2010,the S EC perm itsoiland gascom panies,in theirfilingsw ith the S EC,to disclose only proved,probable

and possible reservesthat m eet the S EC’sdefinitionsforsuch term s. N ew field m ay use term sin thispresentation,such as“resources”,“net resources”,“net

discovered resources”,“net risked resources”,“net low er-risked captured resources”,“net risked captured resources”,“grossresources”,“grossresource

potential”,“grossunrisked resource potential”,“grossunrisked resources”,and sim ilarterm sthat the S EC’sguidelinesstrictly prohibit in S EC filings. Investors

are urged to considerclosely the oiland gasdisclosuresin N ew field’s2013 A nnualR eport on Form 10-K,available at w w w .new field.com ,w w w .sec.govorby

w ritingN ew field at4 W aterw ay S quareP lace,S uite100,T heW oodlands,T exas77380 A ttn:InvestorR elations.

Forw ardL ookingS tatem entsandR elatedM atters

22